Methods and apparatuses for transmission of longitudinal and torque pulse data from drill string in well while drilling

ABSTRACT

Two methods and two mechanisms for carrying out the methods are disclosed. The methods of (1) generating longitudinal or torque pulses at the lower end of a drilling assembly in the bottom of a wellbore at the natural frequency of the drilling assembly, and (2) monitoring the top of the drilling assembly for the longitudinal or torque pulses therein may be practiced by (1) a drill collar rotatably and detachably mounted on a drill bit on the lower end of a drilling assembly in a wellbore for being momentarily and precisely coupled and uncoupled during drilling for generation of longitudinal pulses in the drilling assembly at the natural frequency of the drilling assembly for being monitored at the surface, and (2), respectively, a drill collar rotatable by a plurality of controllable jets exhausting tangentially of the drill collar outer periphery for generating torque pulses in the drilling assembly at the natural frequency thereof for being monitored at the surface.

United States Patent n91 Fowler [4511 May28,1974

[ METHODS AND APPARATUSES FOR TRANSMISSION OF LONGITUDINAL AND TORQUEPULSE DATA FROM DRILL STRING IN WELL WHILE DRILLING [75] Inventor: JoeR. Fowler, Houston, Tex.

[73] Assignee: Texaco, Inc., New York, NY.

[22] Filed: Sept. 29, 1972 [21] Appl. No.: 293,610

[52] US. Cl. 340/18 LD, 340/18 NC [51] Int. Cl Glv 1/40 I58] Field ofSearch ..-340/18 LD, 18 NC [56] References Cited I UNITED STATES PATENTS2,161,256 6/1939 Karcher 340/18 LD 1 3,252,225 5/1966 Hixson 340/18 NC3,520,375 7/1970 Raynal et al. 340/19 LD 3,588,804 6/1971 Fort 340/18 LD3,659,259 4/1972 Chaney et al. 340/18 NC OTHER PUBLICATIONS Barnes etal., Passhands For Acoustic Transmission is an ldealized Drill String,5/72, Pg 1606l608, Journ. Acoust. Soc. of Amer, Vol. 51, No. 5 (Part 2).

Primary Examiner-Maynard R. Wilbur Assistant ExaminerN. MoskowitzAttorney, Agent, or FirmT. H. Whaley; C. G. Reis 5 7 ABSTRACT Twomethods and two mechanisms for carrying out the methods are disclosed.The methods of l) generating longitudinal or torque pulses at the lowerend of a drilling assembly in the bottom of a wellbore at the naturalfrequency of the drilling assembly. and (2) monitoring the top of thedrilling assembly for the iongitudinal or torque pulses therein may bepracticed by 1) a drill collar rotatably and detachably mounted on adrill bit on the lower end of a drilling assembly in a wellbore forbeing momentarily and precisely coupled and uncoupled during drillingfor generation of longitudinal pulses in the drilling assembly at thenatural frequency of the drilling assembly for being monitored at thesurface, and (2), respectively, a drill collar rotatable bya pluralityof controllable jets exhausting tangentially of the drill collar outerperiphery for generating torque pulses in the drilling assembly at thenatural frequency thereof for being monitored at the surface.

-8 Claims, 5 Drawing Figures I -Z/0 33 194 K 324 21.6 9.6 -326METHODSAND APPARATUSES F0 TRANSMISSION OF LONGITUDINAL AND TORQUE PULSEDATA FROM DRILL STRING IN WELL WHILE DRILLING BACKGROUND OF THEINVENTION While drilling wells, such as wells for the recovery ofpetroleum from subsurface petroleum containing formations, there aremany measurements which are desired by people doing the drilling fordetermining the lithology being encountered as the wellbore progressesdeeper and deeper into the earth. The usual practice today during thedrilling of oil and gas wells is'to interrupt the drilling operationperiodically, to pull the entire drill string from the wellbore. and torun logging tools down into the wellbore for detemiining the types ofearth formations which have been penetrated by the wellbore and thecharacteristics of such formation layers indicative of the presence ofpetroleum deposits, and for collecting other information as desiredprior to running the entire drill string back into the wellbore. As thewell gets deeper and deeper, the time required for the removal andrerunning of this drill string, known in the industry as a trip, becomesgreater and greaterf Some wells are so deep as to require 24 hours tomake a trip, plus many additional hours for the running of a loggingtool into the formation. F urtherit has long been realized that it wouldbe highlyv desirable to perform certain basic logging operations duringthe course of the drilling operation, and to transmit such informationback up to the surface either periodically or continually. If this werepossible, it would permit a complete record of the subsurface lithologyto be accumulated as the drilling proceeds and would not necessitate thedelay of drilling operations for the running of logs.

Thus it would be very advantageous, during drilling of record. Others,as inU. S. Pat. No. 3,520,375, have operations of a wellbore, to possessa signal system for the transmission of information from the area of thebottom of the wellbore or the drill bit to the surface using the mostconvenient continuous communications line available, the drill string,as the' communication medium. For many types of information, thesignaldoes not have to-be transmitted continuously during drilling, but can betransmitted at certain intervals. Ex-

cmplary information that is needed very urgently at the surface duringdrilling are borehole deviation, information from drilling tests storedin a memory unit or a warning signal, as a pressure difference detectedand stored when drilling through a gas zone. Thus during drilling itwould be desirous to obtain this informatio as soon as possible.

While a prior signal transmission system comprises modulation of mudpressure or mud flow by a variable valve in the mud conduit in thebottom of the drill pipe, as in U. S. Pat. Nos. 2,930,137; 3,327,527; or

. 3,345,867; this system is not reliable due to sticking of the valvebecause of the solids in the mud and due to failure of the valve becauseof the abrasion thereof by the mud perse. Another prior but differentdata transmission system comprises a controllable wellbore wall engagingmeans extendable transversely from the sides of the drill stem formomentarily increasing the drag or torque in the drill pipe whilerotating the drill pipe for sending torque pulses to the surface throughthe drill string. Thislatter system is disclosed in patent applicationSer. No. 279,899 filed Aug. 1 l. 1972, by Assignee detected themechanical characteristics of rocks being drilled by comparing thevertical vibrations and axial movement of the drilling assembly forcomparison with known rock properties and apparently any resultanttorsional accelerations as the drill bits roll over and grind up therocks.

OBJECTS OF THE INVENTION Accordingly, a primary object of this inventionis to provide at least two reliable methods for transmission of datafrom the bottom of a wellbore to the top while drilling.

Another primary object of this invention is to provide a datatransmission system for practicing one of the new methods utilizing alongitudinal pulse signal generator that may be coupled and uncoupled tothe drill string for precise interruption of v pulse generation thereinwhen drilling for transmitting longitudinal pulses for detection at thetop of the drill string.

Still another object of this invention is to provide a data transmissionsystem utilizing a roller rotating on an annular surface with a bumpthereon that is coupled and uncoupled to a drill string with a mudpressure actuated spring clutch while drilling;

Another object of this invention is to provide a data transmissionsystem utilizing a torque jet pulse generator for generating torquepulses at the natural frequency of the drilling assembly, the jet pulsesbeing controlled with a controller in the drill collar while drilling;

A still further object of this invention is to provide a datatransmission system for continuous transmission of data from a downholetool while drilling which is easy to operate, is of simpleconfiguration, is economical to build and assemble, and is of greaterefficiency for generating signals at the natural frequency of thedrilling assembly from a rotating drill bit deep in a well to thesurface.

BRIEF DESCRIPTION OF THE DRAWINGS The drawings diagrammaticallyillustrate by way of example, not by way of limitation, two forms ormechanisms for carrying out the methods of the invention whereinlikereference numerals have been employed to indicate similar parts inthe several views in which:

FIG. 1 is a schematic vertical view of the invention when incorporatedin an oil or gas well being drilled;

FIG. 2 is a schematic vertical sectional view of the invention asmounted in a drill collar of the drill string of FIG. 1;

FIG. 3 discloses a longitudinal natural frequency curve for a typicalspring-mass system of a drilling assembly; and

FIGS. 4 and 5 discloses a modification of FIG. I having a plurality ofcontrollable jets for generating torque pulses illustrated schematicallyin section.

DESCRIPTION OF THE INVENTION The invention disclosed herein, the scopeof which being defined in the appended claims, is not limited in itsapplication to the details of construction and arrangements of partsshown and described for carrying out the disclosed methods, since theinvention is capable of other embodiments for carrying out other methodsand of being practiced or carried out in various other ways. Also, it isto be understood that the phraseology or terminology employed herein isfor the purpose of description and not of limitation. Further, manymodifications and variations of the invention as hereinbefore set forthwill occur to those skilled in the art. Therefore, all suchmodifications and variations which are within the spirit and scope ofthe invention herein are included and only such limitations should beimposed as are indicated in the appended claims.

DESCRIPTION OF THE METHODS A method is set forth for transmitting datafrom the bottom ofa drill string of a drilling assembly in a wellbore tothe top of the wellbore during drilling thereof comprising the steps of,

l. generating signal pulses in the lower end of the drill string at thenatural frequency of the drilling assembly, and

2. monitoring the top of the drill string for the natural frequencysignal pulses therein.

A more specific method comprises a method for transmission of data fromthe bottom of a drill string of a drilling assembly in a wellbore duringdrilling thereof to a detector at the surface including the steps of,

l sensing the desired parameter ofinformation at the bottom of thewellbore,

2. generating longitudinal pulses at the longitudinal frequency of thedrilling assembly in the bottom of the drilling assembly,

3. modulating the time duration of the longitudinal pulses proportionalto the desired parameter of information sensed, and

4. detecting the modulated pulses at the surface of the wellbore.

An additional and different method for transmission of data from thebottom of a drill string of a drilling assembly in a wellbore duringdrilling thereof to a detector at the surface comprises the steps of.

l. sensing the desired parameter ofinformation at the bottom of thewellbore,

2. generating torque pulses at the torsional natural frequency of thedrilling assembly in the bottom of the drilling assembly,

3. modulating the time duration of the torque pulses proportional to thedesired parameter of information sensed, and

4. detecting the modulated pulses at the surface of the wellbore.

DESCRIPTION OF APPARATUS OR SYSTEMS OF DATA TRANSMISSION FROM A WELLBOREWHILE DRILLING The drawings disclose two embodiments of the inventionfor carrying out or practicing the above described methods fortransmitting intelligence from the bottom of a wellbore of conditions atthe bottom to the surface, either while drilling is in progress orduring a lull in drilling.

FIG. 1 discloses schematically a system for carrying out the basicmethods of data transmission from a wellbore during drilling operations.

In the drilling rig illustrated in FIG. 1, a drilling assembly isdisclosed comprising a derrick II for supporting a traveling block 12with lines 13 having a dead line 14. A hook 15 on the bottom of thetraveling block has a swivel 16 on the bottom thereof for supporting thedrill string 17, the latter comprising a kelly 18 slideabletherethrough,and many interconnected drill pipes 19 for supporting a drill collar 20having a drill bit 21 connected to the bottom thereof. Drill string 17is rotated by rotary table 22 driven by a suitable rotary drive orengine 24 with a sensitive torque meter 2312 connected therebetween.Likewise an analog recorder or sensitive force meter 23a is connected tothe fast line of drilling line 13 for detection of longitudinal pulsesthrough the lines 13.

Field experiments have shown that as the three cone drill bit rotates itgenerates longitudinal vibrations with a predominant frequency of threetimes the rotational speed. A bit rotating at 100 rpm will generate alongitudinal vibration with a predominant frequency of 300 cycles perminute or 5 cycles per second.

It has been found that very strong longitudinal vibrations occur in thedrill string when the rotational speed of the three cone drill bit, andaccordingly the whole drill string, is such that the three times rotaryspeed longitudinal vibration generated by the bit is at the longitudinalnatural frequency of the surface spring-mass system of the drillingassembly (composed of the drilling lines, as the spring and the hook,swivel, traveling block, and drill string as the mass). In fact aformula has been derived for calculating or generating the mostimportant longitudinal natural frequency or critical RPM (revolutionsper minute) of the drill string in the drilling assembly comprising:

RPM=(10/lllVK (32.2)7M

where K combined stiffness of drilling lines (springs) in lb/ft M Massof hook, swivel, traveling block, and drilling lines in lb As thestiffness of the drilling lines depends on their length, this stiffnessand thus the critical RPM will vary slightly as each joint of pipe isdrilled down. The above formula applies when three pulses per revolutionare generated. When any other number (n) of pulses per revolution aregenerated, the required speed is merely the above speed multiplied by3/n.

Also the natural frequency may be determined experimentally, if sodesired.

FIG. 3 illustrates the resultant curve 24 for a typical drillingassembly, which while illustrated as sitting on the ground, it isactually the drilling assembly sitting on the Texaco drilling bargeCaillou" for drilling off the shores of Texas and Louisiana. This curveillustrates the variation of longitudinal vibratory forces developedfrom a three cone drill bit and detected at the top of the drill stringthrough rotary speeds from 40 rpm to 200 rpm for this drilling assemblycomprising a 189 foot tall derrick 11, FIG. 1,' 15,550 pound travelingblock 12, 1 1/2 inch, 4. 16 pound per foot drilling line 13, 14 9,950pound hook l5, 5,400 pound swivel 16, 1 1,463 foot, 5 inch, l9.5 poundper foot steel drill pipe 19, and a 637 foot, 7 inch steel drill collar20. It is seen that between and rpm, the natural frequency of thisparticular drilling assembly, small longitudinal vibrations aremagnified and transmittable great distances, as up through a few milesof drill string. Accordingly, with a longitudinal pulse generator forgenerating pulses longitudinally in the drill pipe from the location ofthe drill collar and drill bit at the natural frequency of the drillingassembly relative to data desired to be transmitted to the surface and alongitudinal pulse monitoring device at the surface connected to the topof the drill string, an apparatus for transmission of data from thebottom of the well is produced.

Likewise, the torsional natural frequency, RPM, was found of the abovedisclosed drilling assembly, it being found by trial and error or bybeing calculated from the formula:

tan (wLp/a) tan (wLc/a) =Jp/Jc where w torsional natural frequency ofthe drill string in radians per second Lp length of drill pipe, inchesLc length of drill collars, inches G material shear modulus ofelasticity g gravitational acceleration 7 weight per unit volume of thedrill string Jp polar moment of inertia of the drill pipe Jc polarmoment of inertia of the drill collars Accordingly, by generatinglongitudinal pulses in the drill bit at the longitudinal naturalfrequency of the drilling assembly; it can beassured that the pulses maybe detectable at the surface for any length 'of drill string with aminimum of input energy at the drill bit. And by modulating the timesequence of pulses at the natural frequency relative to, or equal to afunction of the measured parameter, as temperature or pressure of theformation, wellbore deviation, etc., intelligent data from the bottom ofthe wellbore is easily and efficiently received at the surface.

Further, by generating torque pulses in the drill collar or drill bit atthe torsional natural frequency of the drilling assembly, a pulse iseasily detectable at the surface from any depth with a minimum of inputenergy at the drill bit.

In each case, the transmitter or pulse generator is adjustable l tooperateat different frequencies and thus operate at the naturalfrequency for different drilling rigs and (2) to operate for differentlengths of time relative or proportional to the measured signal at thebottom of the wellbore.

EMBODIMENT OF FIG. 2

A feature of the invention illustrated in the expanded longitudinalsectional view of the upper end of the drill bit 21, FIG. 2, rotatablyconnected internally to a lower end of the drill collar is thelongitudinal natural frequency pulse generator comprising basically aplurality of rollers rotatable over a plurality of bumps andcontrollable with a quick disconnect clutch between the drill collar andthe drill bit for generatinglongitudinal pulses at the natural frequencyof the drilling assembly in the drill string.

Specifically, the pulse generating mechanism comprises two rollers a,25b, FIG. 2, rotatably mounted on the lower end of the drill collar forrolling on an inclined annular surface 26 having four bumps 90 apart,only two bumps 27a and 27b positioned 180 opposite of each other beingillustrated. Controllable connections, pistons, or dogs 28a, 28b in theinner portion of the drill bit 21 are slideable into the respectiverecesses 29a and 29b in the outer lower portion of the drill collar 20as controlled by a conventional electromagnetic valve 30 responsive tosignal inputs from a conventional transducer and valve control system orcontroller 31. In the absence of mud pressure in line 33, tensionsprings 32a and 32b retract dogs 28a and 28b from the recesses to permitrelative rotation between the drill collar 20 and the drill bit 21.While only two dogs 28 and two recesses 29 are illustrated, any suitablenumber may be utilized around the outer periphery of the upper, drillbit portion 21 as required.

Controller 31 is a conventional detector of temperature, pressure,weight on the bit, and of other logging parameters such as SP (selfpotential) or resistivity for operating the clutch dogs 28a, 28b in andout for permitting the drill collar to rotate and generate torque pulsesat the natural frequency and time modulated in proportion to the datatransmitted, such as but not limited to a conventional logging pulsegenerator, all positioned in a measurement and instrumentation moduleportion of controller 31, FIG. 2. Likewise, the controller mayincorporate therein any suitable downhole tape recorder system asdisclosed in US. Pat. No. 3,566,597, for playback when desired.

The sensitive meter 230, FIG. 1, for detecting longitudinal energypulses at the longitudinal natural frequency of the drilling assemblymay be any suitable meter, such as but not limited to a conventionalweight indicator coupled to an analog recorder for producing, forexample, a sine wave plot of amplitude versus time.

While only two dogs 28a, 28!), FIG. 2, two rollers 25a, 25b, and fourbumps 27a 27d are described or illustrated, the desired number of eachmust be utilized in order that the range of number of bumps per secondper revolution of the drilling string will include the predeterminednatural frequency of the particular drilling assembly being operated, asthe number of drill pipes is increased during drilling.

In the practice of my invention, the logging instrument or othermeasuring device performs the desired measurement and the data areconverted into electrical analog signals with the measurementsrepresented by the length of the pulse signal. This is a common form ofmodulation frequently employed in transmitting scientific data. Powerfor operation of the measurement devices and electronics is supplied byconventional batteries (not shown). If desired, the measurement and datatransmission operation may continue more or less continually during thedrilling operation, with the periodic signal pulses being generated andtransmitted to indicate the desired parameters being monitored. Actuallydrilling is interrupted momentarily during actual transmission. In someinstances it is desirable to interrupt the normal drilling operation andactivate the subsurface equipment to have it make measurements andtransmit the measurements back to the surfaceby the signal pulses. Onevery satisfactory method of accomplishing this is to include acentrifugal switch in the measurement and electronics assembly, whichsenses the cessation of rotation of the drill string. When a measurementis desired, the pumps are stopped and the drill bit rotation is stopped.The centrifugal switch will close when the drill string rotation isstopped, and the measurement devices are activated thereby. Thereafterthe measurement is encoded into pulsed analog electrical signals whichare used to activate the wellbore engaging apparatus as is describedhereinabove. Rotation of the 'drill string must be resumed fortransmission of the signal back to the surface.

Still another method of activating the measurement and data transmissionsystems, where it is not desired to transmit data continually during thedrilling cycle, involves the use of conventional strain gauges appliedto a section of the drill collar to sense the amount of weight beingapplied to the bit, which are activated when the drill string is raiseda sufficient distance so that the bit no longer contacts the bottom ofthe wellbore. Either type of switch or both may be used to activate themeasurement and data transmission functions.

Thus in operation of the embodiment of FIG. 2 in practicing the methodset forth above of transmitting data from the bottom of a wellboreduring drilling to a detector at the surface, controller 31 detects orreceives the information to be transmitted, as pressure, average weighton the drill bit, deviation, etc., which is measured and electricallystored and transmitted at the predetermined time set in the system.

The system, FIG. 2, is shown in drilling position wherein drill mudpressure from mud conduit 34a in the center of the drill string forsupplying mud to the drill bit, forces diaphragm 35 inwardly and withthe help of hydraulic reservoir 36 maintain dogs 28a, 28!; extended intorecesses 29a, 29b to lock the drill collar to the drill bit 21 fornormal drilling. Then at the time of transmission, which may becontrolled from above, as by stopping and starting rotation of the drillstring a predetermined number of times, electromagnetic valve is rotatedcounterclockwise 90 degrees to cut off the hydraulic pressure to allowthe hydraulic fluid to flow into air reservoir 37 and as the dogsinstantly retract due to the tension force of springs 32a, 32/) thedrill bit becomes disconnected from the drill collar, and with aconstant load maintained on the bit of between 10,000 and 50,000 pounds,friction holds the bit stopped while the rollers 25a, 25b rotate overthe bumps 27a 27d as the drill string and drill collar are rotated atthe proper and predetermined speed to generate the longitudinal pulsesat the known natural frequency of the drilling assembly. Thepredetermined speed of rotation of the drill string depends on thenumber of longitudinal pulses generated by each turn of the drillstring. For example, if four pulses per turn are generated, the speed ofrotation is merely three-fourths of that speed determined for aconventional three cone roller bit and described by the abovelongitudinal natural frequency formula or determined experimentally. Ascontrolled by the control valve, the pulses are generated at the naturalfrequency for a length of time proportional to the signal, which pulsesare easily detected at the surface by the sensitive force meter 23a.

In the disclosed example of four bumps 27a, 27b, 27c, and 27d (only thefirst two being illustrated on FIG. 2) spaced circumferentially 90 aparton the upper end of the annular drill bit surface, as the drill collarand its two opposite rollers 25a, 25b rotate over the bumps there wouldbe four longitudinal bumps or excitation at a frequency of four timesthe rotary speed. Thus rotating the drill string at one-fourth thepredetermined speed generates the longitudinal natural frequency forthat particular drilling rig having that length of drill string.

Thus at the proper preset time or at the time when sections of drillpipe are to be added, signal pulses at the drilling assembly naturalfrequency may be generated only for the length of time relative to thedata being transmitted.

Accordingly, the drill string is used as the signal transmission systemat the natural frequency of the drilling assembly to overcome drillingmud damping which is circulated continually down the middle of the drillstring to the lower end of the drill bit and back up the annular spaceexternally of the drill string to the surface again. Thus an efficientsignal system is required to overcome all of this damping.

Additional advantages are:

Valve 30 is the only single electromechanical part of this transmissionsystem and thus the only part to be intelligently controlled.

Likewise, all energy for the excitation comes from the rotary drive toaccordingly eliminate the requirement for a large downhole power source.

Further, energy to actuate the dogs into locking engagement comes fromthe mud pumps and the natural hydrostatic mud pressure.

EMBODIMENT OF FIGS. 4 AND 5 FIG. 4 is a schematic elevational view ofthe lower section of a drill collar having a plurality of controllablemud jets for generating torque pulses at the lateral natural frequencyof a drilling assembly as another embodiment for practicing the abovedisclosed methods.

FIG. 5 is a section at 5-5 on FIG. 4.

As the drilling mud is pumped down the interior passage 341), FIG. 4, ofthe drill collar 20b at an examplar pressure of 2,200 psi andcirculating at a typical rate of 400 gallons per minute, a suitableelectromagnetic conventional fluid control valve 30b bleeds off aportion of this flow to eject it from opposite nozzles 39a and 39!),FIG. 5, in pulses having the torsional natural frequency of the drillingassembly as determined experimentally or by the formula above, in shortperiods of time proportional to the data being transmitted at the bottomof the well-bore to the sensitive meter 23b, FIG. 1, at the surface. Aconventional signal measurement and storage system 41, FIG. 5, as fordetecting and storing the bottom hole temperature, bit temperature,weight on the bit, pressure, etc., transmits its information to acontroller 42 for maintaining a sine wave generator 43 on for a lengthof time proportional to the signal. The sine wave generator 43 isbattery powered and is frequency adjustable for controlling theelectromagnetic valve 301; for generating the tortional pulses at thenatural frequency of the drilling assembly for being received by thetorque meter 23b described above. These nozzles 39a and 39b eject thehigh pressure, high velocity mud substantially tangentially from theperiphery of the drill collar from cavities 40a and 40b respectively.

Accordingly, the mud jet nozzles of FIGS. 4 and 5 as controlled byvariable control valve 30b generate lateral or torque pulses at thelateral natural frequency of the drilling assembly for periods of timeproportional to the data to be transmitted.

Obviously other methods may be utilized for transmission of signals withthe embodiments of either FIG. 2 or FIG. 4 than those listed above,depending on the particular information desired to be transmitted.

Accordingly, it will be seen that while drilling is in progress, thedisclosed methods and two data transmission systems will transmitinformation from the bottom of a wellbore to the surface and willoperate in a manner which meets each of the objects set forthhereinbefore.

While only two methods of the invention and two mechanisms for carryingout the methods have been disclosed, it will be evident that variousother methods and modifications are possible in the arrangement andconstruction of the disclosed methods and data transmission systemswithout departing from the scope of the invention and it is accordinglydesired to comprehend within the purview of this invention suchmodifications as may be considered to fall within the scope of theappended claims.

I claim:

1. A method for transmission of data from the bottom portion of adrilling assembly including a drill collar rotatable on a drill bit to adetector at the surface while drilling a wellbore comprising the stepsof,

a. measuring data on the bottom portion of the drilling assembly,

b. forming a bump on the upper end of the drill bit,

b. determining the natural frequency of the drilling assembly, and

c. ejecting drilling fluid from a nozzle tangentially from the outerperiphery of the bottom of the drilling assembly for generating torquepulses relative to the measured data in the drilling assembly at thetorsional natural frequency of the drilling assembly for receiving atthe surface of the wellbore.

5. A system for transmission of data from the lower 10 end of a drillstring of a drilling assembly in a wellbore c. forming a roller on thelower end of the drill collar for rolling over the bump as the drillcollar rotates relative to said drill bit,

d. rotatingthe roller over the bump for generating longitudinal pulsesin the bottom of the drilling assembly at the longitudinal naturalfrequency of the drilling assembly, and

e. modulating the time duration of the generated longitudinal pulsesproportional to the measured'data for receiving at the surface of thewellbore.

2. A system for transmission of data from the lower end of a drillstring ofa drilling assembly in a wellbore to the top of the wellboreduring drilling comprising,

a. a drill string including a drill collar means rotatably mounted on adrill bit means,

b. said drill bit means having a bump on the top thereof and said drillcollar means having a roller on the bottom thereof for rolling over saidbump,

c. data measuring means on the lower end of said drill string,

d. said drill bit means and said drill collar means comprising drill bitlongitudinal pulse generating means on the lower end of said drillstring for generating longitudinal pulses in said drill string at thelongitudinal natural frequency of the drilling assembly proportional tothe measured data, and

e. monitoring means on the upper end of said drill string for monitoringsaid drill bit longitudinal pulses in said drill string.

3. A system as recited in Claim 2 wherein the drill bit longitudinalpulse generating means comprises,

a. controllable coupling means between said drill bit means and saiddrill string,

b. control means for said controllable coupling means, and

c. said coupling means being responsive to said con trol means forcontrolled coupling and uncoupling of said drill bit means from saiddrill string for generating said drill bit torque pulses at thelongitudinal natural frequency of the drilling assembly.

4. A method for transmission of data from the bottom of a drillingassembly to the surface while drilling a 65 LII to the top of thewellbore during drilling comprising,

a. data measuring means on the lower end of the drill string,

b. drill collar torque pulse generating means also on the lower end of adrill string for generating torque pulses in said drill string at thetorsional natural frequency of the drilling assembly, and

c. said controllable torque pulse generating means comprises acontrolled valve operated nozzle for ejecting drilling fluid tangentialto said drill string for generating torque pulses proportional to themeasured data at the torsional natural frequency of the drillingassembly.

6. A system for transmission of data from the lower end ofa drill stringof a drilling assembly in a wellbore to the top of the wellbore duringdrilling comprising,

a. data measuring means on the lower end of the drill string,

b. drill collar in the drill string,

c. controllable torque pulse generating ejection nozzle means on saiddrill collar,

d. control means for said controllable torque pulse generating ejectionnozzle means, and

e. said controllable torque pulse generating ejection nozzle means beingresponsive to said control means for generating said torque pulsesrelative to the measured data at the torsional natural frequency of thedrilling assembly.

7. A method for transmission of data from the bottom of a drill stringincluding a drill collar to a detector at the surface while drilling awellbore comprising the steps of,

a. measuring data at the bottom of the drill string,

b. forming a drilling mud ejecting nozzle in the drill collar forcontrolled ejecting of drilling mud tangentially to the outer peripheryof the drill collar,

c. ejecting the drilling mud in torque pulses at the torsional naturalfrequency of the drill string,

d. modulating the time duration of the generated torque pulses relativeto the measured data for receiving at the surface of the wellbore.

8. A system for transmission of data in a drilling assembly from thebottom of a wellbore to the top of the wellbore while drillingcomprising,

a. a drilling assembly for being lowered into a wellbore including adrill bit at the bottom with a drill collar connected between said drillbit and a string of drill pipes to the surface, and means on the surfacefor rotating said drill pipes,

b. data measuring means on the lower end of said drilling assembly,

c. fluid nozzle means projecting tangentially from the periphery of saiddrill collar for generating torque forces in the bottom of said drillpipes at the natural frequency of the drilling assembly,

f. said torque pulse monitoring means being responsive to said modulatedpulses in said drill pipes for monitoring said data at the surface fromsaid control means at the bottom of the wellbore.

1. A method for transmission of data from the bottom portion of adrilling assembly including a drill collar rotatable on a drill bit to adetector at the surface while drilling a wellbore comprising the stepsof, a. measuring data on the bottom portion of the drilling assembly, b.forming a bump on the upper end of the drill bit, c. forming a roller onthe lower end of the drill collar for rolling over the bump as the drillcollar rotates relative to said drill bit, d. rotating the roller overthe bump for generating longitudinal pulses in the bottom of thedrilling assembly at the longitudinal natural frequency of the drillingassembly, and e. modulating the time duration of the generatedlongitudinal pulses proportional to the measured data for receiving atthe surface of the wellbore.
 2. A system for transmission of data fromthe lower end of a drill string of a drilling assembly in a wellbore tothe top of the wellbore during drilling comprising, a. a drill stringincluding a drill collar means rotatably mounted on a drill bit means,b. said drill bit means having a bump on the top thereof and said drillcollar means having a roller on the bottom thereof for rolling over saidbump, c. data measuring means on the lower end of said drill string, d.said drill bit means and said drill collar means comprising drill bitlongitudinal pulse generating means on the lower end of said drillstring for generating longitudinal pulses in said drill string at thelongitudinal natural frequency of the drilling assembly proportional tothe measured data, and e. monitoring means on the upper end of saiddrill string for monitoring said drill bit longitudinal pulses in saiddrill string.
 3. A system as recited in Claim 2 wherein the drill bitlongitudinal pulse generating means comprises, a. controllable couplingmeans between said drill bit means and said drill string, b. controlmeans for said controllable coupling means, and c. said coupling meansbeing responsive to said control means for controlled coupling anduncoupling of said drill bit means from said drill string for generatingsaid drill bit torque pulses at the longitudinal natural frequency ofthe drilling assembly.
 4. A method for transmission of data from thebottom of a drilling assembly to the surface while drilling a wellborecomprising the steps of, a. measuring data at the bottom of the drillingassembly, b. determining the natural frequency of the drilling assembly,and c. ejecting dRilling fluid from a nozzle tangentially from the outerperiphery of the bottom of the drilling assembly for generating torquepulses relative to the measured data in the drilling assembly at thetorsional natural frequency of the drilling assembly for receiving atthe surface of the wellbore.
 5. A system for transmission of data fromthe lower end of a drill string of a drilling assembly in a wellbore tothe top of the wellbore during drilling comprising, a. data measuringmeans on the lower end of the drill string, b. drill collar torque pulsegenerating means also on the lower end of a drill string for generatingtorque pulses in said drill string at the torsional natural frequency ofthe drilling assembly, and c. said controllable torque pulse generatingmeans comprises a controlled valve operated nozzle for ejecting drillingfluid tangential to said drill string for generating torque pulsesproportional to the measured data at the torsional natural frequency ofthe drilling assembly.
 6. A system for transmission of data from thelower end of a drill string of a drilling assembly in a wellbore to thetop of the wellbore during drilling comprising, a. data measuring meanson the lower end of the drill string, b. drill collar in the drillstring, c. controllable torque pulse generating ejection nozzle means onsaid drill collar, d. control means for said controllable torque pulsegenerating ejection nozzle means, and e. said controllable torque pulsegenerating ejection nozzle means being responsive to said control meansfor generating said torque pulses relative to the measured data at thetorsional natural frequency of the drilling assembly.
 7. A method fortransmission of data from the bottom of a drill string including a drillcollar to a detector at the surface while drilling a wellbore comprisingthe steps of, a. measuring data at the bottom of the drill string, b.forming a drilling mud ejecting nozzle in the drill collar forcontrolled ejecting of drilling mud tangentially to the outer peripheryof the drill collar, c. ejecting the drilling mud in torque pulses atthe torsional natural frequency of the drill string, d. modulating thetime duration of the generated torque pulses relative to the measureddata for receiving at the surface of the wellbore.
 8. A system fortransmission of data in a drilling assembly from the bottom of awellbore to the top of the wellbore while drilling comprising, a. adrilling assembly for being lowered into a wellbore including a drillbit at the bottom with a drill collar connected between said drill bitand a string of drill pipes to the surface, and means on the surface forrotating said drill pipes, b. data measuring means on the lower end ofsaid drilling assembly, c. fluid nozzle means projecting tangentiallyfrom the periphery of said drill collar for generating torque forces inthe bottom of said drill pipes at the natural frequency of the drillingassembly, d. control means for said fluid nozzle means for modulatingthe pulses generated relative to data to be transmitted to the surface,e. torque pulse monitoring means at the top of the drill pipes, and f.said torque pulse monitoring means being responsive to said modulatedpulses in said drill pipes for monitoring said data at the surface fromsaid control means at the bottom of the wellbore.